In recent years, South-Eastern Europe (SEE) has experienced a notable transformation in its electricity markets, moving away from a traditional focus on capacity towards a more nuanced understanding of flexibility as the critical constraint. This shift underscores the need for electricity systems to adapt to rapid changes in demand and supply, particularly in light of increasing integration of variable renewable energy sources.
The dynamics of the SEE market have become increasingly evident, particularly during periods of meteorological variability. For instance, during early January 2026, spot prices in the region saw a significant decrease from €94.82/MWh to €89.73/MWh, driven by a surge in wind generation and a dip in demand post-holidays. This 8.4% reduction was accompanied by substantial increases in wind output, which rose by approximately 125% week-on-week.
However, the subsequent price volatility highlights the underlying challenges faced by the region’s electricity system. Within just one week, average prices rebounded sharply to €111.36/MWh—a 24.1% increase—as various factors including weather shifts and cross-border constraints exerted pressure on market pricing mechanisms. By Week 03, prices surged further, with Serbia experiencing an astonishing 65.5% rise compared to previous weeks.
This pattern of rapid price changes is indicative of a broader issue: the limited flexibility within the system to manage such fluctuations effectively. In more advanced electricity markets, these price swings are typically mitigated through extensive balancing mechanisms and interconnections that allow for real-time adjustments based on supply and demand conditions.
The flexibility gap is particularly pronounced during peak demand periods in both summer and winter months. For example, summer 2024 witnessed extreme price spikes reaching as high as €1,000/MWh during evening hours—an alarming statistic that reflects not just high demand but also the inability of the system to import necessary flexibility when needed most. Analysis from ACER indicated that nearly half of these spikes could have been avoided if cross-zonal capacity adhered to EU’s 70% availability requirement.
Moreover, this scarcity of flexibility is compounded by reliance on traditional thermal plants for inertia and balancing functions within SEE grids. As climate variability affects hydropower reliability—an essential source of flexibility—the region increasingly turns to fossil fuel imports for balancing needs. This reliance highlights an urgent requirement for enhanced storage solutions and demand-side response strategies that remain underdeveloped across SEE markets.
The European Electricity Balancing Guideline has initiated efforts toward establishing common platforms for balancing energy exchanges among transmission system operators (TSOs). Platforms such as PICASSO and MARI are designed to facilitate regional cooperation in managing flexibility resources effectively, thereby reducing overall system costs and minimizing price volatility.
However, achieving deeper integration into these balancing frameworks requires alignment across national grid codes and operational readiness among participating countries. The Energy Community’s ongoing efforts toward market coupling are crucial for facilitating this integration process—allowing for shared flexibility resources that can alleviate scarcity issues across borders.
As market participants increasingly prioritize flow control and volatility management over mere generation ownership, there is evidence that flexibility is becoming a monetizable asset within the region’s trading behavior. January 2026 reports indicated revitalized liquidity flows and heightened cross-border trading activities as traders began to capitalize on market volatility.
Strategically, it is clear that SEE’s future power landscape will hinge on its ability to build out a robust framework for operational flexibility rather than simply announcing new capacities. Essential components include enhancing interconnector availability, advancing market coupling initiatives, engaging with European balancing platforms effectively, deploying scalable storage solutions, and developing credible demand response programs tailored for large consumers.
The economic implications of this shift are profound; recent data indicates that addressing flexibility shortages could significantly lower peak pricing—potentially reducing evening peak prices by up to €78/MWh under optimal conditions for cross-zonal capacity availability. As observed fluctuations illustrate how quickly flexibility deficits can translate into cost burdens for consumers and industry alike, it becomes imperative for policymakers to recognize this interplay between capacity and operational resilience.
Ultimately, addressing the flexibility gap presents both a challenge and an opportunity for South-Eastern Europe’s energy sector. By investing in flexible solutions rapidly enough, the region can align itself more closely with European stability benchmarks while mitigating long-term volatility risks associated with its electricity markets.
